Method and Apparatus For Magnetic Ranging While Drilling

ABSTRACT

Methods, devices and systems are disclosed for magnetically ranging while drilling with a coiled tubing unit or drill pipe by way of a an electrically conducive but environmentally electrically insulated wire installed through a coiled tubing spool or drill pipe complete with electrically insulative subs in the coiled tubing bottom hole assembly or drill pipe. The method and systems allow for the injection of excitation current into the formation by way of selectively electrifying various drill stem components, thereby facilitating current collection on a target tubular which radially emanates a magnetic field about the target well tubular(s). The method and devices allow for the construction of complex downhole current injection configurations which allow for modification of the bottom hole assembly to maximize target well signal generation in the presence of adverse environmental conditions.

FIELD OF THE INVENTION

The present disclosure relates to devices and methods involved withperforming measurements from a subterranean wellbore or other suchunderground void to produce a relative distance and direction from onepoint in three-dimensional space to another. In particular, the presentdisclosure utilizes a novel along hole current isolation and deliverysystem and method that conducts electrical energy to a bottom holesubsurface location so as to induce a measurable signal from aconductive member in a target wellbore in order to allow a bearing andrange between wellbores to be calculated.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.17/482,045, filed Sep. 22, 2021, now U.S. Pat. No. ______, which claimsthe benefit of U.S. Provisional Patent Application Ser. No. 63/216,861,filed Jun. 30, 2021 and U.S. Provisional Patent Application Ser. No.63/081,692, filed Sep. 22, 2020, each of which is hereby incorporated byreference in its entirety.

BACKGROUND OF THE INVENTION

The requirement to establish relative points in three dimensions fromsurface to subsurface position, from subsurface positions to othersubsurface positions, or from a subsurface position to a surface orsubsea position has long been present. Typically referred to as ranging,the practice of calculating a distance and directional between points inspace below the surface of the earth are well known and readilycommercially available in industry.

A ranging determination is typically accomplished by deploying a signalsource in one wellbore, and a receiver of said source in an adjacentwellbore. This arrangement can be swapped around to take advantage of asystems accuracy, ease of deployment or other convenience available to aparticular operation. In most cases, two wellbores can be accessed witheither the source or receiver of ranging signals, however, in somecircumstances, access to an offset wellbore is not possible. Ofparticular concern is the situation where a wellbore has been lost dueto a catastrophic event, such as a well fire or uncontrolled release ofhydrocarbon, often referred to as a blowout. For all intents andpurposes, access to a well may also be lost even without a fire orblowout. In some instances, the wellbore hole or casing can collapse orshear, making it practically impossible to access the wellboreconcentrically down the inner diameter of the wellbore tubulars. Inthese situations, the damaged wellbore may need to be permanentlyplugged.

In the event of a blowout or plugging operation, the relative proximitybetween a drilling well and the blowout well is of critical importance,as a primary control technique of an out of control oil well is thedeliberate intersection of the wild well with another wellbore. Theintersection described allows for the control of the wild well by way ofhydraulically pumping heavy mud and cement through the drilling wellinto the target blowout well. This operation, typically referred to asrelief well drilling, requires by design the direct and deliberatecontact and communication between wellbores at some deep and exact pointin three-dimensional space. This is routinely accomplished by way ofranging, and has historically been addressed by magnetic rangingmethods. The magnetic ranging method deployed in a relief well operationis unique however, in that the source and receiver of the signal can bethought of as being contained in a common assembly lowered into thedrilling well (relief well) via a long wireline. It is necessary then tobe able to induce signal on the target blowout and subsequently detectthat signal with the common wireline assembly as there are no options toinstall a source or receiver of ranging signal in a wild well that is onfire.

The process of both creating a source of magnetic signal from a targetwell and receiving this signal from the same assembly in the drillingwell is also well known and commercially available from at least twoservice providers. The assembly in question is deployed via wireline andcontains an electrode that is mounted several hundred feet from adownhole receiver. Electrical power is transmitted down a multiconductorwireline and delivered into the formation in the drilling well. Injectedcurrent tends to collect preferentially on the nearby target well casingand flow axially along its length. This current has associated with it amagnetic field, and it is this magnetic field that is subsequentiallydetected by the wireline receiver below the electrode in the drillingwell. A bearing and distance to the target well can be calculated fromthe sensor measurements, and the trajectory of the drilling well can bere-deigned to intersect with the casing of the blowout well. Thisprocess is described in U.S. Pat. No. 4,372,398.

A drawback of this approach relates to the fact that the ranging systemreferenced above must be deployed via wireline. This fact necessitatesthat the drilling assembly be retracted from the borehole whenever aranging measurement is required. In practice, multiple rangingmeasurements will be performed in a single well in order to ensure thatthe target and drilling well intersect at the appropriate point. Thisiterative wireline-drilling-wireline-drilling process is time consumingand expensive.

To solve this problem, several inventions have been proposed tostreamline the wireline deployed method. One such method, described inU.S. Pat. No. 8,695,730, seeks to contain in the drilling assembly acurrent source which will be separated via an electrically insulativegap sub in the assembly. This technique suffers a serious drawback,however, in that the effective circuit for current flow is localizedabout the drilling assembly. The effective circuit that is createddownhole does not include or severely limits the along well current flowpath of the target well tubular, and therefore sufficient signal for aranging determination is often not achievable.

Another attempt to more closely align the preferred target wellexcitation technique with a true “while drilling” approach is the use ofa wireline electrode deployed inside the drill pipe of the drillingassembly. This method is detailed in U.S. Pat. No. 9,759,060. While thistechnique can allow for a broader excitation of nearby target wellboretubulars, it still involves the cessation of drilling for extendedperiods of time while wireline is deployed concentrically in the drillstring, albeit without having to withdraw the drill string entirely.This approach is risky, however, in that it involves maintaining thedrill string more or less stationary for the duration of the datacollection process. This exposes the operation to mechanical andhydraulic sticking of the drill string, a non-trivial matter which oftenresults in the permanent loss of the bottom hole assembly and drillpipe, and the permanent loss of the drilled hole and associated progresstowards intersection with the target blowout well.

The present inventions seek to eliminate entirely the need for any sortof wireline deployment of instruments related to either excitation ordetection, while maintaining the efficiency of target well excitationand overall range and accuracy of detection typically delivered by thewireline technique described in U.S. Pat. No. 4,372,398.

SUMMARY OF THE INVENTION

Novel systems and methods are disclosed for performing magnetic rangingwhile drilling. The novel system includes a bottom hole assembly with asensor that is at least sensitive to a magnetic ranging signal. Thenovel system also includes a drill pipe portion or a non-rotatingdrilling pipe portion (coiled tubing may be used as the non-rotatingdrilling pipe portion) and at least one electrically insulative gap subor similar device that influences the movement and direction ofelectrical energy from the drillstring into the earth/strata surroundingthe well. The system also includes an electrical power supply capable ofbeing connected at a point in the drillstring so that current can beinjected into the earth/strata through the drillstring, and canaccumulate on a target well and create a magnetic ranging signal.

The novel method disclosed involves the steps of inserting a bottom holeassembly containing a sensor sensitive to a magnetic range signal into awell bore. Connecting an electrical power source to a wire at anappropriate point in the drillstring. Inserting electrically insulativegap sub(s) or similar device(s) into the well bore to influence themovement and direction of electrical energy from the drillstring intothe surrounding earth/strata and onto the borehole pipe of a targetwell. Energizing the power source so that current passes from thedrillstring into the surrounding earth/strata and creates a magneticranging signal on a target well. Sampling/collecting the magneticranging signal created by the target well and adjusting the angle ordirection of drilling.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is an example of a bottom hole assembly of a coiled tubingdrilling rig assembly.

FIG. 2 is an example of a current injection system using gap subs toprevent downhole current flow and sensor contamination.

FIG. 3 is an example of a bracketed current injection apparatus thatcreates a ranging signal about a target well pipe.

FIG. 4 is an example of a drilling system using coiled tubing toimplement a ranging while drilling system.

FIG. 5 is an example of a drilling set up and current injection systemusing various subs and/or shorting mechanisms to pass current into thereservoir.

FIG. 6 is an example of a current injection system using separatecurrent flow conductors in a drill string.

FIG. 7 is an example of a flow through sub in a current injectionsystem.

FIG. 8 is an example of a shorting mechanism used in the currentinjection system.

FIG. 9A is an example of a single conductor in a drill pipe with aninsulating material on one side.

FIG. 9B is an example of two conductors in a drill pipe with insulatingmaterial surrounding the conductors.

FIG. 9C is an example of a connector used to connect the conductors of acurrent injection system.

DETAILED DESCRIPTION

The present disclosure relates to systems and methods for performingmagnetic ranging while drilling. An example using coiled tubing whiledrilling is described in one embodiment, however, any non-rotating pipeor other mechanism can be used as the drillstring, which is alsodescribed herein.

To preserve the efficacy of target well excitation, a method of surfacegrounding referenced energy transfer is used. Specifically, the surfacepower supply that sends electrical energy downhole is grounded tosurface and delivers electrical energy to some distance point at or nearthe bottom of a drilling well, which in the case of a relief welloperation, could be miles from the surface position of the drilling rigand excitation power supply. To transmit power and deliver it withoutthe use of an insulated wire, the drill pipe of the drilling well caninstead be crafted to allow for an insulated path through whichelectrical current can flow. This can be done while minimizing leakagealong the current path length, while minimizing the overall electricalresistance encountered by electrons in the circuit, and can be directedprecisely to an electrical current delivery point which is typicallysome hundreds of feet near the deepest point in the drilling well.

FIG. 1 depicts an exemplary bottom hole assembly of a drilling rig usingcoiled tubing. Bottom hole assemblies may comprise of motors, steeringmechanisms, orienting motors and other devices as identified in FIG. 1 .More or less components than are identified in FIG. 1 can also make upthe bottom hole assembly. Within the coiled tubing is run a multiline101 to deliver power to various sensors and equipment in the bottomholeassembly. The individual conductors in the multiline are typically usedto establish bi-directional communications with a plurality of downholesensors involved with formation evaluation and directionally drillingthe wellbore. These instruments include but are not limited to gamma raysensors, pressure sensors, directional drilling steering sensors, andmagnetic range sensors, amongst many others. Another common use of someof the multi conductors present in the pre-installed wireline bundleincludes the delivery of power (electrical energy) to a downhole device.For example, in some coiled tubing directional drilling systems,electrical energy is delivered to a downhole electrical motor by way ofseveral conductors of the multi-line bundle. The motor turns to orientthe bent housing of a hydraulically driven mud motor, thereby enablingthe coiled tubing operator to intentionally orient and therefore steeror deviate the trajectory of the wellbore. This, of course, is but oneuse of the multi-conductor lines. In the same spirit, some of themulti-conductor lines can also be assigned to target well excitation.Specifically, one or more of the multi-conductor lines can be connectedon surface to a magnetic ranging current injection power supply, andused to deliver an excitation current into the formation at or near thebottom hole assembly (downhole terminus) of the coiled tubing unit. Theconnection to the coiled tubing can also be made at any point in the runof the tubing, including at surface. Since the coiled tubing assemblydoes not rotate about its long axis, the wire installed on the ID of thetubing spool can be permanently installed in the coil as they cannotentangle or break. Alternatively, one or more separate conductor(s) froma current injection power supply can be connected to the coiled tubingto supply current down the coiled tubing and into the formation tocreate a magnetic ranging signal on a target well. As with theconnection of conductors of a multiline conductor, these conductors canbe connected to the coiled tubing at any location on surface or withinthe wellbore. Depending on the place of connection, conductors can betemporarily connected to the coiled tubing or permanently connected tothe coiled tubing.

To accomplish magnetic ranging as described herein, as shown in FIG. 2 ,current is delivered in the coiled tubing to a specific point 201 in thedrillstring or bottom hole assembly. As before, the current supplied viaan electrical conductor 205 can be from one or more conductors of amulticonductor line, or can be one or more separate conductors. As shownin FIG. 2 , structure also substantially prevents current from flowingto the distal end of the pipe where the sensors are located andsubstantially prevents current from flowing back up the coiled tubingtowards the surface. As shown in FIG. 2 , electrically insulative gapsubs 202 are shown. These gap subs are designed to force current 203 toinject at one or more points along the drill string, or allow theinjection to occur over some length of the drill string, therebymaximizing or minimizing surface area over which electrical current canflow into the formation. The gap sub has an electrical discontinuityalong its length, but still allows for mechanical integrity of thecoiled tubing to remain. This can be accomplished by a ceramic layerthat is press fit or heat fit between steel elements of the sub. Thosefamiliar with the state of the art will acknowledge that this is but oneway of several well know methods to create an electrically insulativegap sub. The sub must also either force the electrical short circuit ofthe inner conductive element of the drill pipe to the exterior of thedrill pipe, or allow the current to pass through the insulative gap andbe delivered downhole. (as shown in FIG. 3 ) Both configurations aredesirable depending on the specific downhole circumstances. Toaccomplish the direct short circuit of injection current, one or moreinjection wires can be terminated to the sub above (uphole from) itsinsulation point. When delivered above the electrical discontinuity ofthe sub, the current injected tends to flow up the coiled tubing pipe,but also flows through formation and onto the target well casing,thereby creating the desired magnetic ranging signal 204.

On some occasions, it is also desirable to inject current into theformation at a specific depth along the long axis of the coiled tubingsystem. This is shown in FIG. 3 . To accomplish this, more than one gapsub 301 can be installed in the bottom hole assembly or drillstring.These subs can be thought of as bracketing the excitation point, withone or more gap subs uphole of the excitation point, and one or more gapsubs below the excitation point. These subs essentially force current toflow on a specific portion of the bottom hole assembly or drillstringand subsequently flow into the formation as a result of metal to earthcontact of the bracketed section of the coiled tubing pipe, andthereafter the current flows onto the target well 302. An example ofthis type of configuration for creating a magnetic ranging signal in atarget well is shown in FIG. 3 .

It is important to note that the apparatus described above ensures thatcurrent is injected in the section of the coil pipe bracketed by theuphole and downhole gap subs. This is a requirement of certain reliefwells and other ranging contexts, as the injection of current at aparticular section of the coil pipe allows for the management ofenvironmental effects which tend to reduce the efficacy of the currentinjection method. These effects include but are not limited to,formation heterogeneity, drilling fluid composition, formationresistivity and target well tubular discontinuities. The aforementionedgap sub can therefore be thought of as being able to simultaneously“flow through” current and drilling fluid, a feature that is ofimportance to the operation of the present invention.

Current injection and magnetic ranging while drilling is accomplished bythe apparatus disclosed herein. Current is injected in the vicinity of atarget, without removing the drill stem. With current emanating into theformation, and a distal return path for the driving surface powersupply, the physics described in U.S. Pat. No. 4,372,398 has beenpreserved. A plurality of magnetometers, accelerometers and gyroscopesembedded in the bottom hole drilling assembly can sample the target wellsignal, and a bearing and distance to the target can be readilycalculated. The raw sensor data can be transmitted to surface viaindustry standard telemetry methods, or the computed bearing andproximity information can be calculated via an onboard microprocessor,and the resulting information transmitted accordingly.

FIG. 4 shows an example of the ranging while drilling operation using acoiled tubing drilling rig. The method of preparing for and deployingthe apparatus is as follows:

-   -   1. Install in the drilling bottom hole assembly or drillstring a        sensor 402 that is at least sensitive to the magnetic ranging        signal 204 that is to be created on the target well 302    -   2. Install electrically insulative gap subs 301 or similar in        the bottom hole assembly or drillstring so as to influence/force        the flow of electrical energy 203 into the earth/strata and onto        the target well 302 while isolating current from flowing on and        contaminating/negatively influencing the magnetic field        measurement acquisition of the sensor embedded in the bottom        hole assembly    -   3. Install and electrically connect at least one wire from the        coiled tubing wire bundle (found on the inside diameter of the        coiled tubing), or a separate conductor, to a point in the        drillstring that has been suitably electrically isolated as per        step #2.    -   4. Connect the wire(s) that have been grounded to the        drillstring downhole (as per step 3) to a surface magnetic        ranging current injection power supply    -   5. Drill the well as per normal, or trip the bottom hole        assembly into a previously drilled well    -   6. When a relative bearing and distance from the drilling well        to the target well is desired/required, energize the surface        power supply from step #4.This will subsequently inject current        into the formation at or near the gap sub arrangement which was        installed in the bottom hole assembly in Step 2. Current will        flow through the formation, collect on the target well, and a        resulting magnetic ranging signal is thus created.    -   7. Sample/query the sensor installed in the bottom hole assembly        during step #1. The sensor can have integral to it a        microprocessor which computes the magnetic ranging distance and        direction, along with other information, and transmit the        “answers” to surface via various telemetry methods, or the raw        data sampled from the sensor can be transmitted to surface and        the ranging information be calculated on surface by the surface        computer. If the sensor microprocessor computes the answer        downhole, the information could be passed directly to an        autonomous drilling system to be actioned during drilling (e.g.        positional ranging information could be passed to an autonomous        rotary steerable system and be actioned downhole without human        intervention or interpretation)    -   8. Using the magnetic ranging answer from step 7 to adjust        operations to achieve the particular goal of the deployment.        E.g. replan the drilling well to intersect the target well,        replan the drilling well to avoid the target well, replan the        drilling well to stay in close proximity to the target well,        etc. The describe steps need not be completed in any particular        order, and one of skill in the art would know that some steps        can be completed before or after others.

In another embodiment, the apparatus contains three parts, a surface subwhich allows for the injection of current into the drill string at thedrill floor, a current path along the drill pipe made up of multiplepipe sections, and the isolation and gap subs at or near the distal endof the drill string which allow for control over the precise injectionpoint of the electrical energy responsible for target well excitation.FIG. 5 shows an example of magnetic ranging while drilling system. Thesystem uses drill pipe 500 connected in sections. A surface sub 501transmits current from an electrical source 502 to the drill string. Acurrent carrying mechanism 503 is carried on the inside of the drillstring to allow current to be carried down the drill string. A flowthrough sub 504 is provided in the drill string and a standard gap sub505 is also provided. In this arrangement, current passes down the drillstring through the flow through sub until it hits the gap sub. Thepresence of the gap sub prevents current from flowing further downholeand causes current to enter the material adjacent the drill string(e.g., subterranean formation). As current leaves the drill string itwill travel through the subterranean formation to contact a target well506. A magnetic field 507 is created and detected by a sensing unit 508located at or near the distal end of the drill string.

Alternatives to gap subs, for example, other shorting mechanisms, canalso be used. Shorting mechanisms can be used to replace one or more gapsubs in the system described herein. An example of a shorting mechanismis shown in FIG. 8 . The shorting mechanism brings the electricalconnectors carried by the drill string together to create a shortcircuit, thus providing an alternative mechanism to direct the currentcarried by the conductor in the drill string to the subterraneanformation. In FIG. 5 , the vertical arrows represent current beingcarried by the conductor of the drill string and the angular arrowsrepresent flow of electrons into the subterranean formation.

The surface sub which transmits electrical energy from the power supplyto the drill pipe will typically be installed in the rotating member ofthe top drive robot and provide an insulated channel through whichcurrent can flow, be attached to the injection power supply, and allowfor rotation while power is being delivered. This can readily beaccomplished by a brush and rotor arrangement, similar to a commutatorassembly in any electrical turning machine. Alternative current deliverymethods and devices can also be used.

The multiple drill pipes which will make up sections of the long currentchannel leading to the distal end of the bore contain at least oneisolated conductive element. The isolation for this element can provideinsulation from the drill pipe body itself, along with the electricallyconductive fluid that will be pumped down the drill pipes. One solutionfor this has been described in application US20190119990, where aradially expansive conductive element is used to line the interior of anindustry standard drill pipe. This conductive member is both insulatedfrom the ID of the drill pipe and the drilling fluid being pumped downthe drill pipe by an electrically insulative epoxy coating. However, theconductive member may also be insulated from the drill pipe by anyconventional method known by one of skill in the art, one example beingan epoxy coated drill pipe containing a conductive element that isinsulated from the body of the drill pipe but is not insulated from thefluid pumped down the drill pipe. It is important to note that theinventions disclosed herein are meant to deliver electrical power intothe formation. As a result, the preferred embodiments of the inventionsdisclosed involves coating a section or all of the ID of a commercialpipe with a nonconductive material such as epoxy, and then installingone or more ribbons of insulated conductor into the epoxy layer as showin FIGS. 9A-9C. FIG. 9A shows a section of drill string coated on itsinner diameter with an insulating material such as epoxy 901. A currentcarrying mechanism 902, such as an insulated or uninsulated ribbon, abraided wire, an impregnated material or any suitable conductor islocated in close proximity to, or embedded into, the insulatingmaterial. FIG. 9B shows an example of two separate conductors 902 and903. Each conductor/ribbon can land on either side of the drill pipe onone or more conductive rings, or on a ring that is stepped so as toallow for separate “channels” to be dedicated to each ring andconductor/ribbon pair. This allows for additional configurations ofcurrent injection and return paths, an arrangement which will bediscussed at length in a forthcoming section of this disclosure. FIG. 9Cshows an example of a mechanism for connecting the conductive rings asdescribed. In this example, the two separate conductors are connectedusing a step connection. Conductor 903 is contacted using a smallerdiameter ring 904 and conductor 902 is contacted using larger ring 905.The ring assures contact from box to pin of the drill pipes when jointsof pipe are added to the drill stem. As will be appreciated by one ofskill in the art, there are multiple manners in which to contact/connectthe conductors of each segment of drill pipe while isolating eachconductor, thus providing multiple paths for current flow.

Another embodiment of the invention involves a three-step coatingprocess that layers nonconductive and conductive coatings inside acommon piece of pipe. Firstly, a non-conductive epoxy is coated insidethe ID of the pipe. Next, the conductive ring is installed on each endof the pipe and a second conductive layer of silver (or other conductivematerial) impregnated epoxy (or similar insulating material) is applied.Finally, an additional layer of non-conductive epoxy (or similarinsulating material) is installed. This has the effect of protecting theinner conductive layer from electrical contact with both the drill pipeand the drill pipe fluids, all while providing an insulated current pathfor excitation energy to be transmitted from surface. Another embodimentcould use braided wires or other conductive wiring between epoxy (orsimilar insulating material) layers to provide similar insulation of thedrill pipe and drilling fluids.

FIG. 6 is an example of using magnetic ranging with separate conductorsinside of the drill string. In this example, gap sub 601 causes currentflow from drill string that is carried by conductor 903 and enterformation above the gab sup. Separate conductor 902 provides for theflow of current from the surrounding formation and back to surface.

FIG. 7 is an example of a flow through sub. In this exemplary flowthrough sub, ceramic material 701 prevents current flow from the drillpipe uphole, while conductor 903 provides for connection 702 to the bodyof the drill pipe and allows current to flow from the drill pipe to thesurrounding formation. Conductor 902 may carry current uphole, orfurther downhole for injection at another point closer to the distal endof drill string. As will be appreciated by one of skill in the art, acombination of flow through subs and gab subs can be used to injectcurrent at different precise locations along the drillstring.

The inventions disclosed herein can use different types of currentsand/or frequencies and can be sampled and analyzed using one or moredevices to optimize the magnetic ranging while drilling methodsdisclosed.

To perform magnetic ranging, current is directed to inject at a specificpoint or points along the drill pipe and be prevented from flowing tothe distal end of the pipe where the sensors that are used for magneticranging will be housed. This is accomplished by electrically insulativegap subs or other electrically insulative devices which will effectivelyforce current to inject at one or more points along the drill string, orallow the injection to occur over some length of the drill string,thereby maximizing or minimizing surface area over which electricalcurrent can flow into the formation. The “Gap sub” can have anelectrical discontinuity along its length, but still allow formechanical integrity of the drill string to remain. This can beaccomplished by a ceramic layer that is press fit or heat fit betweensteel elements of the sub. Such electrically insulative “gap” subs arereadily available in industry. The sub can either force the electricalshort circuit of the inner conductive element of the drill pipe to theexterior of the drill pipe, or allow the current to pass through theinsulative gap and be delivered downhole. Both configurations aredesirable depending on the specific downhole circumstances and can beaccommodated. To accomplish the direct short circuit of injectioncurrent, the box end of the sub can contain a ring which bothelectrically connects the insulated conductive element to the outer ODof the drill pipe and gap sub.

To pass current through the gap sub, a similar arrangement as has beendescribed by the pipe manufacturing process detailed above can bedeployed. This allows for the up-hole current to be delivered below theceramic gap in the isolation sub. In another embodiment, this short subcan easily be gun drilled and one or more insulated conductors installedin the axial channel created in the sub body. These conductors caneither be shorted to the OD of the sub body once past the insulativegap, or be shorted to the lower half of the drill string by way of amodified conductive ring described above and pictured in FIG. 7 . It isimportant to note that the apparatus described ensures that current isinjected in the section of pipe bracketed by the uphole and downhole gapsubs. The injection of current at a particular section of the drill pipeallows for the management of environmental effects which tend to reducethe efficacy of the current injection method. These effects include butare not limited to, formation heterogeneity, drilling fluid composition,formation resistivity and target well tubular discontinuities. Theaforementioned gap sub can therefore be thought of as being able tosimultaneously “flow through” current and drilling fluid, which enablesthe current inventions.

FIG. 8 is an example of a shorting mechanism as describe herein.Conductive points 801 can be used to connect conductor 902 and 903 suchthat they are short circuited.

Current injection in the vicinity of the target, without removing thedrill stem, can be achieved using the inventions disclosed. Furthermore,current delivered can be maximized due to the availability of a lowimpedance circuit that is available by greater effective conductor crosssectional area as compared to a typical wireline conductor gauge size.With current emanating into the formation, and a distal return path forthe driving surface power supply, the physics described in U.S. Pat. No.4,372,398 has been preserved. As described in the cited prior art, aplurality of magnetometers, accelerometers and gyroscopes embedded inthe drilling assembly can now sample the target well signal, and abearing and distance to the target can be readily calculated. The rawsensor data can be transmitted to surface via industry standardtelemetry methods, or the computed bearing and proximity information canbe computed via an onboard microprocessor, and the resulting informationtransmitted accordingly.

An appropriate isolating physical or solid state disconnect can beinstalled in the drill stem, and the channelized conductors in the drillstem was passed to the downhole near bit measurement system, themicroprocessor could use the channelized conductors to transmit the dataor information after the excitation and magnetic field sampling eventhad concluded. This would allow for faster bi-directional communicationsbetween up hole and subsurface processors but comes with the requirementof electrical isolation.

While the inventions have been illustrated and described in detail inthe drawings and foregoing description, the same is to be considered asillustrative and not restrictive in character, it being understood thatonly the preferred embodiments have been shown and described and thatall changes and modifications that come within the spirit of theinventions are desired to be protected.

What is claimed is:
 1. An apparatus for magnetic ranging comprising: apower supply; at least one section of drill pipe configured to beoperatively connected to the power supply; at least one wire inside theat least one section of drill pipe that connects the power supply andthe at least one section of drill pipe, wherein the connection betweenthe wire and the drill pipe is a rigid connection that is capable ofmaintaining its rigid connection as the at least one section of drillpipe is drilling; a first electrically insulated member electricallyconnected with the at least one section of drill pipe and that iscapable of causing electrical energy to exit a section of drill pipe;and a sensor for detecting a magnetic ranging signal.
 2. The apparatusof claim 1 further comprising a second electrically insulated memberlocated further downhole from the first electrically insulated member.3. The apparatus of claim 1 wherein the sensor is part of the bottomhole assembly.
 4. The apparatus of claim 1 wherein the sensor is part ofthe drill pipe.
 5. The apparatus of claim 1 wherein the drill pipe iscoiled tubing.
 6. The apparatus of claim 1 wherein the drill pipe is asection of threaded_drill pipe.
 7. The apparatus of claim 1 wherein thepower supply is connected to the drill pipe using at least one wire of amultiribbon wire.
 8. The apparatus of claim 1 wherein the power supplyis connected to the drill pipe using one or more conductors.
 9. Anapparatus for magnetic ranging comprising: a power supply; at least onesection of drill pipe operatively connected to the power supply; atleast one wire inside the at least one section of drill pipe thatconnects the power supply and the at least one section of drill pipe,wherein the connection between the wire and the drill pipe is a rigidconnection and is not spring loaded; a first electrically insulatedmember electrically connected with the at least one section of drillpipe and that is capable of causing electrical energy to exit a sectionof drill pipe; and a sensor for detecting a magnetic ranging signal. 10.The apparatus of claim 9 further comprising a second electricallyinsulated member located further downhole from the first electricallyinsulated member.
 11. The apparatus of claim 9 wherein the sensor ispart of the bottom hole assembly.
 12. The apparatus of claim 9 whereinthe sensor is part of the drill pipe.
 13. The apparatus of claim 9wherein the drill pipe is coiled tubing.
 14. The apparatus of claim 9wherein the drill pipe is a section of threaded drill pipe.
 15. Theapparatus of claim 9 further comprising a second electrically insulatedmember located further downhole from the first electrically insulatedmember.
 16. The apparatus of claim 9 wherein the power supply isconnected to the drill pipe using at least one wire of a multiribbonwire.
 17. The apparatus of claim 9 wherein the power supply is connectedto the drill pipe using one or more conductors.
 18. An apparatus formagnetic ranging comprising: a power supply; at least one section ofdrill pipe configured to be operatively connected to the power supply;at least one wire inside the at least one section of drill pipe thatconnects the power supply and the at least one section of drill pipe,wherein the connection between the wire and the drill pipe is capable ofmaintaining a continuous electrical connection while the at least onesection of drill pipe is drilling; a first electrically insulated memberelectrically connected with the at least one section of drill pipe andthat is capable of causing electrical energy to exit a section of drillpipe; and a sensor for detecting a magnetic ranging signal.
 19. A methodof magnetic ranging comprising: installing a sensor that senses amagnetic ranging signal in a wellbore; installing a first electricallyinsulative gap sub in a wellbore; installing at least one section ofdrill pipe in a wellbore that is connected to the electricallyinsulative gap sub; connecting a power supply to at least one section ofdrill pipe using at least one wire that is located inside the at leastone section of drill pipe, wherein the connection from the at least onewire to the at least one section of drill pipe is made at surface and isa rigid connection; energizing the power supply to cause current to flowdown the drill pipe and inject into a wellbore formation and travel to atarget well to create a magnetic ranging signal; sampling the magneticranging signal; and adjusting the drilling operations to alter acharacteristic of the drilling operations.
 20. The method of claim 19further comprising adjusting the drilling operations to alter acharacteristic of the drilling operations.
 21. The method of claim 19further comprising installing a second electrically insulative gap subdownhole from the first electrically insulative gap sub.
 22. The methodof claim 19 wherein the step of sampling the magnetic ranging signaloccurs while drilling is taking place.